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Legislative counsel reviews Vermont’s renewable energy standard tiers, post-Act 179
Summary
A Legislative Council attorney gave Natural Resources & Energy members a statutory overview of Vermont’s Renewable Energy Standard, explaining the five-tier structure, recent changes under Act 179, which utilities are covered, and key dates and percentage targets for meeting 100% renewable electricity.
A Legislative Council attorney summarized Vermont’s Renewable Energy Standard and changes made under Act 179 during the Natural Resources & Energy committee meeting on January 31. The presentation walked members through the statute’s structure, the different utility classes subject to the standard, and numerical targets and time lines tied to tiers for distributed generation, customer electrification measures and new renewable sources.
The Renewable Energy Standard (RES) requires retail electricity providers to source a defined percentage of annual load from renewable energy. The presenter said utilities may comply by owning generation, purchasing renewable energy credits (RECs), or a mix, and that the Public Utility Commission (PUC) and the Department of Public Service supply the detailed accounting and verification. The attorney highlighted that the RES is codified in 30 V.S.A. chapter 189 and that Act 179 adjusted several compliance dates and carve-outs.
Why it matters: the tiered RES shapes utilities’ procurement and customer programs and sets statewide expectations for reaching 100% renewable electricity. Utilities’ compliance paths and the statute’s carve-outs affect local generation, distributed resources and electrification programs that customers use, such as heat-pump incentives or electric-vehicle programs.
Most of the presentation explained the five tiers and the practical implications for different utility types: - Tier 1 (total renewables): Each utility must reach an overall renewable portfolio target; the presenter said utilities were placed on schedules to reach 100% by either 2030 or 2035 depending on utility class. The attorney stated utilities must source a large portion of their annual load from renewables (the presenter cited 63% as a baseline number in current accounting) and that the statute allows banking of RECs and an alternative compliance payment as a backstop (used only once, the presenter said). - Tier 2 (distributed generation): Distributed resources under 5 MW that are new (post‑Jan. 1, 2010) and connected to the distribution system are required to supply a rising share of load. The presenter gave the sample starting point of 5.8% in 2025 with annual increases that reach 20% by either 2032 or 2035 depending on utility class; she noted utilities may count certain older hydro resources they owned by 2024 toward this bucket in order to limit local rate impacts. - Tier 3 (customer electrification and fossil-fuel reduction): This tier allows utilities to count verified greenhouse‑gas reductions achieved by customer electrification programs (EV incentives, heat pumps, weatherization, commercial electrification). Starting in 2025 the presenter said the tier was 7.33% of annual load and grows incrementally to 12% by 2032 for most utilities, with lower percentages for very small municipal utilities. - Tier 4 (new renewables of any size): A carve-out requiring a share of load be met by new renewable plants sited and built after Jan. 1, 2010; the presenter described phased percentage increases and exemptions for utilities already at 100%. - Tier 5 (low-growth requirement): For utilities already at 100% renewables, added load growth above a 2024 baseline must be met with new renewables according to a stepped schedule between 2025 and 2035.
The attorney explained definitions used in the statute: “retail electricity provider” is limited to distribution utilities (Velco is the state’s transmission utility and not subject to the retail RES targets), “renewable energy” excludes nuclear and most solid-waste incineration but includes methane from landfills and anaerobic digestion, and large hydroelectric facilities (200 MW or more) are counted as existing renewable but generally not as “new renewable” for certain tier accounting. She noted utilities were given some flexibility under Act 179 to choose compliance paths consistent with their size and ownership (investor‑owned, co‑op, municipal, or the special case GlobalFoundries).
Committee members asked operational questions about accounting and verification: the presenter said utilities file annual REC/accounting reports in March and that the Department of Public Service does verification and monitors prices; she reiterated that alternative compliance payments have been virtually unused. She also said the PUC’s rules flesh out many of the operational details and recommended consulting the PUC or the Department of Public Service for REC pricing or tight accounting questions.
The presentation closed with a reminder that some utilities—Burlington Electric Department, Washington Electric Co‑op and Swanton—were already at 100% renewable. The attorney urged committee members to direct specific technical questions about REC accounting, pricing, and verification to the Department of Public Service and PUC staff who maintain the detailed records.
The discussion was informational: no committee action or vote occurred on the RES during the session. Members said the overview would be useful background as they consider future electricity-related bills and requested follow-up briefings on PUC and Department accounting practices.
